EP1247787A1 - Rotary seal for directional drilling tools - Google Patents
Rotary seal for directional drilling tools Download PDFInfo
- Publication number
- EP1247787A1 EP1247787A1 EP20020251373 EP02251373A EP1247787A1 EP 1247787 A1 EP1247787 A1 EP 1247787A1 EP 20020251373 EP20020251373 EP 20020251373 EP 02251373 A EP02251373 A EP 02251373A EP 1247787 A1 EP1247787 A1 EP 1247787A1
- Authority
- EP
- European Patent Office
- Prior art keywords
- valve assembly
- sealing surface
- rotary valve
- voids
- rotary
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
Images
Classifications
-
- C—CHEMISTRY; METALLURGY
- C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
- C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
- C04B41/00—After-treatment of mortars, concrete, artificial stone or ceramics; Treatment of natural stone
- C04B41/80—After-treatment of mortars, concrete, artificial stone or ceramics; Treatment of natural stone of only ceramics
- C04B41/91—After-treatment of mortars, concrete, artificial stone or ceramics; Treatment of natural stone of only ceramics involving the removal of part of the materials of the treated articles, e.g. etching
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B22—CASTING; POWDER METALLURGY
- B22F—WORKING METALLIC POWDER; MANUFACTURE OF ARTICLES FROM METALLIC POWDER; MAKING METALLIC POWDER; APPARATUS OR DEVICES SPECIALLY ADAPTED FOR METALLIC POWDER
- B22F7/00—Manufacture of composite layers, workpieces, or articles, comprising metallic powder, by sintering the powder, with or without compacting wherein at least one part is obtained by sintering or compression
- B22F7/06—Manufacture of composite layers, workpieces, or articles, comprising metallic powder, by sintering the powder, with or without compacting wherein at least one part is obtained by sintering or compression of composite workpieces or articles from parts, e.g. to form tipped tools
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B23—MACHINE TOOLS; METAL-WORKING NOT OTHERWISE PROVIDED FOR
- B23B—TURNING; BORING
- B23B27/00—Tools for turning or boring machines; Tools of a similar kind in general; Accessories therefor
- B23B27/14—Cutting tools of which the bits or tips or cutting inserts are of special material
- B23B27/141—Specially shaped plate-like cutting inserts, i.e. length greater or equal to width, width greater than or equal to thickness
- B23B27/145—Specially shaped plate-like cutting inserts, i.e. length greater or equal to width, width greater than or equal to thickness characterised by having a special shape
-
- C—CHEMISTRY; METALLURGY
- C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
- C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
- C04B35/00—Shaped ceramic products characterised by their composition; Ceramics compositions; Processing powders of inorganic compounds preparatory to the manufacturing of ceramic products
- C04B35/515—Shaped ceramic products characterised by their composition; Ceramics compositions; Processing powders of inorganic compounds preparatory to the manufacturing of ceramic products based on non-oxide ceramics
- C04B35/52—Shaped ceramic products characterised by their composition; Ceramics compositions; Processing powders of inorganic compounds preparatory to the manufacturing of ceramic products based on non-oxide ceramics based on carbon, e.g. graphite
-
- C—CHEMISTRY; METALLURGY
- C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
- C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
- C04B41/00—After-treatment of mortars, concrete, artificial stone or ceramics; Treatment of natural stone
- C04B41/45—Coating or impregnating, e.g. injection in masonry, partial coating of green or fired ceramics, organic coating compositions for adhering together two concrete elements
- C04B41/459—Temporary coatings or impregnations
-
- C—CHEMISTRY; METALLURGY
- C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
- C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
- C04B41/00—After-treatment of mortars, concrete, artificial stone or ceramics; Treatment of natural stone
- C04B41/53—After-treatment of mortars, concrete, artificial stone or ceramics; Treatment of natural stone involving the removal of at least part of the materials of the treated article, e.g. etching, drying of hardened concrete
-
- C—CHEMISTRY; METALLURGY
- C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
- C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
- C04B41/00—After-treatment of mortars, concrete, artificial stone or ceramics; Treatment of natural stone
- C04B41/80—After-treatment of mortars, concrete, artificial stone or ceramics; Treatment of natural stone of only ceramics
- C04B41/81—Coating or impregnation
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B10/00—Drill bits
- E21B10/46—Drill bits characterised by wear resisting parts, e.g. diamond inserts
- E21B10/56—Button-type inserts
- E21B10/567—Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
- E21B10/5671—Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts with chip breaking arrangements
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/10—Valve arrangements in drilling-fluid circulation systems
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F16—ENGINEERING ELEMENTS AND UNITS; GENERAL MEASURES FOR PRODUCING AND MAINTAINING EFFECTIVE FUNCTIONING OF MACHINES OR INSTALLATIONS; THERMAL INSULATION IN GENERAL
- F16K—VALVES; TAPS; COCKS; ACTUATING-FLOATS; DEVICES FOR VENTING OR AERATING
- F16K25/00—Details relating to contact between valve members and seat
- F16K25/005—Particular materials for seats or closure elements
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B22—CASTING; POWDER METALLURGY
- B22F—WORKING METALLIC POWDER; MANUFACTURE OF ARTICLES FROM METALLIC POWDER; MAKING METALLIC POWDER; APPARATUS OR DEVICES SPECIALLY ADAPTED FOR METALLIC POWDER
- B22F5/00—Manufacture of workpieces or articles from metallic powder characterised by the special shape of the product
- B22F2005/001—Cutting tools, earth boring or grinding tool other than table ware
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B22—CASTING; POWDER METALLURGY
- B22F—WORKING METALLIC POWDER; MANUFACTURE OF ARTICLES FROM METALLIC POWDER; MAKING METALLIC POWDER; APPARATUS OR DEVICES SPECIALLY ADAPTED FOR METALLIC POWDER
- B22F2998/00—Supplementary information concerning processes or compositions relating to powder metallurgy
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B22—CASTING; POWDER METALLURGY
- B22F—WORKING METALLIC POWDER; MANUFACTURE OF ARTICLES FROM METALLIC POWDER; MAKING METALLIC POWDER; APPARATUS OR DEVICES SPECIALLY ADAPTED FOR METALLIC POWDER
- B22F2999/00—Aspects linked to processes or compositions used in powder metallurgy
Definitions
- This invention relates to a rotary seal for a directional drilling tool, which is useful when drilling boreholes into the earth.
- a rotary steerable tool may be used in a drill string to change the direction of the borehole. It may also be desirable to correct for deviations from the desired direction when drilling a straight hole. Furthermore, directional drilling tools may also be used to control the direction of the hole to avoid obstacles.
- bias units within these rotary steerable tools comprise a number of hydraulic actuators spaced apart around the periphery of the unit.
- Each actuator may have a movable thrust member which is hydraulically displaced outwardly for engagement with the formation of the borehole being drilled.
- each actuator also has an inlet passage for connection to a source of drilling fluid under pressure and an outlet passage communicating the annulus of the borehole.
- a selector control valve connects the inlet passages in succession to the source of fluid under pressure as the bias unit rotates.
- each movable thrust member is displaced outwardly at the same rotational position so as to bias the drill laterally and therefore control the direction of drilling.
- Rotary steerable tools are typically designed as a single unit comprising a selector control valve assembly, a plurality of actuators, and logic systems to control these actuators.
- the valves In operation, however, because power to actuate the valve assembly is limited, the valves have been known to stick.
- One probable reason for these valves sticking is the force applied to the valve by the differential pressure of the drilling fluid. Particularly, when the valve is initially actuated, this hold down force can require the starting torque of the valve to be higher than the torque available in the actuator. In the past, this condition has caused failure of the tool and an expensive trip of the drill string from the hole.
- the interconnected voids allow fluid pressure to equalize between the sealing faces by allowing flow through the interconnecting voids to the sealing surfaces. Because the fit of the sealing surfaces of the valve is less than perfect, and because the voids on mating surfaces do not necessarily overlap, the 5% of the surface area comprising interconnected voids can easily translate to a 10% or more reduction in sealed area when both sealing surfaces have the interconnecting voids. This additional 10% total reduction in surface area subjected to differential pressure has substantially eliminated the hydraulic lock problem encountered upon startup.
- the rotary valve assembly may be made of a polycrystalline diamond material.
- the polycrystalline diamond may be formed with a binder-catalyzing material in a high-temperature, high-pressure process.
- the polycrystalline diamond has a plurality of partially bonded diamond or diamond-like crystals forming at least one continuous diamond matrix, and the interstices among the diamond crystals forming at least one continuous interstitial matrix containing a catalyzing material.
- the polycrystalline diamond has a sealing surface where a portion of the interstitial matrix adjacent to the sealing surface is substantially free of the catalyzing material, and the remaining interstitial matrix contains the catalyzing material.
- the portion of the interstitial matrix free of the catalyzing material forms a porous sealing surface with at least about 5% of its surface area comprising interconnected voids with an average depth D of at least 0.02 mm.
- the rotary valve assembly may be made of cermets, ceramics and reaction bonded silicon carbide.
- the sealing surface is treated to cause voids to form to a depth D from the sealing surface a distance of at least 0.02 mm.
- the selector valve bodies are processed such that at least about 5% of the sealing surface area is formed with interconnected voids extending to a depth D from the sealing surface of at least 0.02 mm.
- bottom hole assembly When drilling directional boreholes into earthen formations, it is common practice to use a bottom hole assembly as shown in Figure 1.
- the bottom hole assembly generally indicated as 10, is typically connected to the end of the tubular drill string 12 which is typically rotatably driven by a drilling rig 8 from the surface.
- the drilling rig 8 In addition to providing motive force for rotating the drill string 12, the drilling rig 8 also supplies a drilling fluid under pressure through the tubular drill string 12 to the bottom hole assembly 10.
- the drilling fluid is typically laden with abrasive material, as it is repeatedly re-circulated through the borehole.
- components of the bottom hole assembly 10 include a drill bit 14, a modulated bias unit 16, and a roll stabilized control unit 18.
- the bias unit 16 is connected to and controlled by the roll stabilized control unit 18, which controls operation of the bias unit 16 in accordance with a pre-determined program or in accordance with signals transmitted to control unit 18 from the surface.
- the bias unit 16 may be controlled to apply a lateral bias to the drill bit 14 in the desired direction so as to control the direction of the drilling.
- the modulated bias unit 16 comprises an elongated main body structure 20 provided at its upper end with a threaded pin 22 for connecting via an end to the roll stabilized control unit 18, which is in turn connected to the end of the drill string 12.
- the modulated bias unit 16 has an elongated main body structure 20.
- the lower end 24 of the body structure 20 is formed with a socket 26 to receive the threaded pin of the drill bit 14.
- the drill bit 14 may be of any type.
- each actuator 28 is supplied drilling fluid under pressure through a passage 30 in the bias unit 16 under control of a valve assembly 32.
- a portion of the valve assembly 32 is rotated relative to the bias unit 16 to divert the pressurized drilling fluid supplied from the surface sequentially to the actuators 28 in turn.
- the rotation is controlled by the roll stabilized control unit 18 in synchronism with the rotation of the drill bit 14 and in selective phase relation thereto.
- each actuator 28 is therefore displaced outwardly at the same rotational position so as to bias the drill bit 14 laterally, and therefore control the direction of drilling.
- valve assembly 32 An enlarged cross sectional view of the valve assembly 32 of the present invention is shown in Figure 3.
- the valve assembly 32 is contained within a valve assembly housing 52 and has a control shaft 33 which is driven by the roll stabilized control unit 18.
- Within the valve assembly 32 is an upper seal 34, an upper bearing 36 contained in a spring housing 38.
- the spring housing 38 has a load spring 40 and related hardware to apply a preload as will be explained later.
- the valve assembly 32 has a lower bearing 42 and a lower seal 44.
- control shaft 33 transmits torque to a rotor assembly 46 through the spring housing 38 to a rotating selector valve body 48.
- the spring housing 38 and load spring 40 are arranged such that in operation the load spring 40 applies a pre-load through the rotor assembly 46 and rotating selector valve body 48 to the stationary selector valve body 50.
- the terms "rotating" and “stationary” referring to the two selector valve bodies is relative to the body 20 of the bias unit 16 and are provided here for convenience in describing the present invention. Since the bias unit 16 is rotated with respect to the earth in operation, the rotating selector valve body 48 may well be stationary with respect to the earth when driven by the roll stabilized control unit 18.
- a first sealing surface 54 on the rotating selector valve body 48 is configured as a partial circular section, as illustrated.
- one of the outlet orifices 58 in the stationary selector valve body 50 is exposed to the pressurized drilling fluid within the valve assembly housing 52.
- These outlet orifices 58 are sequentially exposed in operation by the rotating selector valve assembly 48 to be in fluid communication with passages (for example passage 30) to provide fluid to operate the actuators 28, as earlier described.
- the differential pressure of the pressurized drilling causes the first sealing surface 54 to load onto the second sealing surface 56.
- portions 56 of the total face area of the stationary selector valve body 50 are relieved to reduce the surface area of the stationary selector valve body 50 exposed to the differential pressure of the drilling fluid.
- the size of the outlet orifices 58 limits the total area of the stationary selector valve body 50 that can be relieved. Therefore, the amount of surface area reduction is limited by the mechanical constraints of the valve. Typically, no more than about 50% of the total face area of the stationary selector valve body 50 can be relieved. What remains is the sealing area. This does reduce the torque required to operate the valve assembly 32. However, although relieving the sealing surface 56 allows for more reliable operation, the differential pressure acting on the valve faces causes the valve assembly 32 to stick at times in operation.
- the load spring 40 also urges the sealing surfaces 54, 56 back into contact during times in operation when they may separate. Although this is an unusual situation, it is possible that without the load spring 40, sealing surfaces 54, 56 would remain separated, rendering the tool inoperative.
- either or both of the selector valve bodies 48, 50 are made of a material that is processed to provide the sealing surfaces 54, 56 with a porous structure.
- the rotating selector valve body 48 with the sealing surface 54 will be used to illustrate its operation, structure and composition. This is not intended to limit the invention to this particular valve body in any manner, as the porous structure may be in either or both of sealing surfaces 54, 56 of selector valve bodies 48, 50.
- One method to provide this porous structure is to make either or both selector valve bodies 48, 50 of a polycrystalline diamond material.
- the polycrystalline diamond may be formed with a binder-catalyzing material in a high-temperature, high-pressure process.
- the polycrystalline diamond has a plurality of partially bonded diamond or diamond-like crystals having an average crystal size of from about 0.01 mm to 0.1 mm or larger in diameter. These crystals form at least one continuous diamond matrix, and the interstices among the diamond crystals forming at least one continuous interstitial matrix containing a catalyzing material.
- the polycrystalline diamond has a sealing surface 54 where a portion of the interstitial matrix adjacent to the sealing surface 54 is substantially free of the catalyzing material, and the remaining interstitial matrix contains the catalyzing material.
- the portion of the interstitial matrix adjacent to the sealing surface 54 that is free of the catalyzing material forms a porous surface with at least about 5% of its surface area comprising interconnected voids 60 with an average depth D of at least 0.02 mm from the surface 54.
- the voids 60 In order for the voids 60 to be interconnected below the surface 54, they need to extend from the surface 54 to a depth greater than the average diameter of the crystals.
- the depth D of the interconnected voids 60 from the surface 54 is a distance of at least 0.05 mm. The increased depth allows a more rapid equalization of pressures and provides more material at the sealing surface 54 in the event it should wear in use.
- selector valve bodies 48, 50 include cermets, ceramics and reaction bonded silicon carbide.
- the sealing surface 54 is treated to cause voids 60 to form below the surface 54.
- the voids could be introduced into the selector valve bodies 48, 50 during forming.
- the selector valve bodies 48, 50 are processed such that at least about 5% of the sealing surface 54 area is formed with interconnected voids 60 extending to a depth D from the sealing surface 54 of at least 0.02 mm.
- sealing surface 54 with at least about 5% of its surface area comprising interconnected voids 60 with an average depth D from the sealing surface 54 of at least 0.02 mm.
- the interconnected voids 60 allow fluid pressure to equalize between the sealing faces by flowing through the interconnecting voids 60 to the sealing surfaces 54, 56. Because the fit of the sealing surfaces 54, 56 valve is less than perfect, and because the voids on mating surfaces do not necessarily overlap, the 5% of the surface area comprising interconnected voids 60 can easily translate to a 10% or more reduction in sealed area when both sealing surfaces 54, 56 have the interconnecting voids 60. This additional 10% total reduction in surface area subjected to differential pressure has substantially eliminated the hydraulic lock problem encountered upon startup.
Abstract
Description
- This application claims priority from U.S. Provisional Patent Application Serial No. 60/281,054 incorporated by reference herein by Nigel Griffin and Peter Hughes, filed April 2, 2001, now pending.
- This invention relates to a rotary seal for a directional drilling tool, which is useful when drilling boreholes into the earth.
- When drilling boreholes into sub-surface formations, it is desirable to be able to vary the direction of drilling. For example to direct the borehole toward a desirable target or to control the direction, a rotary steerable tool may be used in a drill string to change the direction of the borehole. It may also be desirable to correct for deviations from the desired direction when drilling a straight hole. Furthermore, directional drilling tools may also be used to control the direction of the hole to avoid obstacles.
- Typical rotary steerable tools are shown for example in U.S. Patents 5,603,385; 5,520, 255 and 5,706,905 all herein incorporated by reference for all they disclose. Typically, bias units within these rotary steerable tools comprise a number of hydraulic actuators spaced apart around the periphery of the unit. Each actuator may have a movable thrust member which is hydraulically displaced outwardly for engagement with the formation of the borehole being drilled. Typically, each actuator also has an inlet passage for connection to a source of drilling fluid under pressure and an outlet passage communicating the annulus of the borehole. A selector control valve connects the inlet passages in succession to the source of fluid under pressure as the bias unit rotates. This modulates the fluid pressure supplied to each actuator in synchronism with the rotation of the drill bit and in selective phase relation thereto. As a result, as the drill bit rotates, each movable thrust member is displaced outwardly at the same rotational position so as to bias the drill laterally and therefore control the direction of drilling.
- Rotary steerable tools are typically designed as a single unit comprising a selector control valve assembly, a plurality of actuators, and logic systems to control these actuators. In operation, however, because power to actuate the valve assembly is limited, the valves have been known to stick. One probable reason for these valves sticking is the force applied to the valve by the differential pressure of the drilling fluid. Particularly, when the valve is initially actuated, this hold down force can require the starting torque of the valve to be higher than the torque available in the actuator. In the past, this condition has caused failure of the tool and an expensive trip of the drill string from the hole.
- It was initially believed that the valves became stuck due to a tribological buildup between the valve faces as described in U.S. Patent 5,560,716 incorporated herein by reference for all it discloses. This patent describes a tribological buildup of the cobalt binder material on the faces of heavily loaded polycrystalline diamond bearing elements, leading to an increase in the operating torque. The patent teaches that this buildup can be alleviated by an acid wipe. However, since the sticking often occurred on initial startup, there was no relative rotation of the valve bodies under load to cause this tribological buildup, so any benefit from this treatment was at best only partially effective. Therefore, it is now believed that other factors independent of the valve material composition contribute to problem, as will be described.
- Another problem with these prior art valve assemblies is that during operation, pressure surges in the drilling fluid can suddenly increase the load on the valve such that the operating torque of the valve exceeds the torque available by the actuator. It is believed that this is caused by the hydrostatic pressure being exerted across the relatively smooth surface of these selector valves exceeding the hydrodynamic lubrication effect of the fluid.
- An additional problem with these units has been a sudden reverse flow of drilling fluid through the valve assembly caused under conditions when the source of pressurized fluid at the surface has been suddenly stopped or when one or more of the actuators are rapidly forced closed. This has been known to cause the valve surfaces to become separated. Since the valve design relies upon the differential pressure of the drilling fluid to provide sealing force, when the valve faces become separated, there is sometimes not enough differential pressure to force the valve surfaces back into contact.
- Disclosed is a rotary valve assembly for directing flow of an abrasive laden drilling fluid, the valve assembly comprising a first sealing surface rotatably engaging a second sealing surface. At least one of the surfaces has at least about 5% of its area comprising interconnecting voids to an average depth of at least 0.02 mm.
- The interconnected voids allow fluid pressure to equalize between the sealing faces by allowing flow through the interconnecting voids to the sealing surfaces. Because the fit of the sealing surfaces of the valve is less than perfect, and because the voids on mating surfaces do not necessarily overlap, the 5% of the surface area comprising interconnected voids can easily translate to a 10% or more reduction in sealed area when both sealing surfaces have the interconnecting voids. This additional 10% total reduction in surface area subjected to differential pressure has substantially eliminated the hydraulic lock problem encountered upon startup.
- The rotary valve assembly may be made of a polycrystalline diamond material. The polycrystalline diamond may be formed with a binder-catalyzing material in a high-temperature, high-pressure process. The polycrystalline diamond has a plurality of partially bonded diamond or diamond-like crystals forming at least one continuous diamond matrix, and the interstices among the diamond crystals forming at least one continuous interstitial matrix containing a catalyzing material. The polycrystalline diamond has a sealing surface where a portion of the interstitial matrix adjacent to the sealing surface is substantially free of the catalyzing material, and the remaining interstitial matrix contains the catalyzing material. The portion of the interstitial matrix free of the catalyzing material forms a porous sealing surface with at least about 5% of its surface area comprising interconnected voids with an average depth D of at least 0.02 mm.
- Alternatively, the rotary valve assembly may be made of cermets, ceramics and reaction bonded silicon carbide. After the selector valve bodies are made to their final shape, the sealing surface is treated to cause voids to form to a depth D from the sealing surface a distance of at least 0.02 mm. The selector valve bodies are processed such that at least about 5% of the sealing surface area is formed with interconnected voids extending to a depth D from the sealing surface of at least 0.02 mm.
-
- Figure 1 is a perspective view of a bottom hole assembly within the earth typically used in the practice of the present invention.
- Figure 2 is a partial cross section view of a modulated bias unit containing the valve assembly of the present invention.
- Figure 3 is a cross sectional view of the valve assembly of the present invention.
- Figure 4 is an end view of the stationary valve face of the valve assembly of the present invention.
- Figure 5 is an end view of the rotating valve face of the valve assembly of the present invention.
- Figure 6 is a micro-structural representation of the areas adjacent to the sealing surface of the valve assembly of the present invention.
-
- When drilling directional boreholes into earthen formations, it is common practice to use a bottom hole assembly as shown in Figure 1. The bottom hole assembly, generally indicated as 10, is typically connected to the end of the
tubular drill string 12 which is typically rotatably driven by adrilling rig 8 from the surface. In addition to providing motive force for rotating thedrill string 12, thedrilling rig 8 also supplies a drilling fluid under pressure through thetubular drill string 12 to thebottom hole assembly 10. The drilling fluid is typically laden with abrasive material, as it is repeatedly re-circulated through the borehole. In order to achieve directional control while drilling, components of thebottom hole assembly 10 include adrill bit 14, a modulatedbias unit 16, and a roll stabilizedcontrol unit 18. Thebias unit 16 is connected to and controlled by the roll stabilizedcontrol unit 18, which controls operation of thebias unit 16 in accordance with a pre-determined program or in accordance with signals transmitted tocontrol unit 18 from the surface. Thebias unit 16 may be controlled to apply a lateral bias to thedrill bit 14 in the desired direction so as to control the direction of the drilling. - Referring now to Figure 2, the modulated
bias unit 16 comprises an elongatedmain body structure 20 provided at its upper end with a threadedpin 22 for connecting via an end to the roll stabilizedcontrol unit 18, which is in turn connected to the end of thedrill string 12. As previously described, the modulatedbias unit 16 has an elongatedmain body structure 20. Thelower end 24 of thebody structure 20 is formed with asocket 26 to receive the threaded pin of thedrill bit 14. Thedrill bit 14 may be of any type. - There are provided around the periphery of the
bias unit 16, a plurality of equally spacedhydraulic actuators 28. Eachactuator 28 is supplied drilling fluid under pressure through apassage 30 in thebias unit 16 under control of avalve assembly 32. In operation, a portion of thevalve assembly 32 is rotated relative to thebias unit 16 to divert the pressurized drilling fluid supplied from the surface sequentially to theactuators 28 in turn. The rotation is controlled by the roll stabilizedcontrol unit 18 in synchronism with the rotation of thedrill bit 14 and in selective phase relation thereto. As is well known, as thedrill bit 14 rotates, each actuator 28 is therefore displaced outwardly at the same rotational position so as to bias thedrill bit 14 laterally, and therefore control the direction of drilling. - An enlarged cross sectional view of the
valve assembly 32 of the present invention is shown in Figure 3. Thevalve assembly 32 is contained within avalve assembly housing 52 and has acontrol shaft 33 which is driven by the roll stabilizedcontrol unit 18. Within thevalve assembly 32 is anupper seal 34, anupper bearing 36 contained in aspring housing 38. Thespring housing 38 has aload spring 40 and related hardware to apply a preload as will be explained later. Finally, thevalve assembly 32 has alower bearing 42 and alower seal 44. - In operation, the
control shaft 33 transmits torque to arotor assembly 46 through thespring housing 38 to a rotatingselector valve body 48. Thespring housing 38 andload spring 40 are arranged such that in operation theload spring 40 applies a pre-load through therotor assembly 46 and rotatingselector valve body 48 to the stationaryselector valve body 50. - In this specification, the terms "rotating" and "stationary" referring to the two selector valve bodies is relative to the
body 20 of thebias unit 16 and are provided here for convenience in describing the present invention. Since thebias unit 16 is rotated with respect to the earth in operation, the rotatingselector valve body 48 may well be stationary with respect to the earth when driven by the roll stabilizedcontrol unit 18. - Referring now to Figures 5 and 6, a
first sealing surface 54 on the rotatingselector valve body 48 is configured as a partial circular section, as illustrated. When thefirst sealing surface 54 is properly aligned with thesecond sealing surface 56, one of the outlet orifices 58 in the stationaryselector valve body 50 is exposed to the pressurized drilling fluid within thevalve assembly housing 52. These outlet orifices 58 are sequentially exposed in operation by the rotatingselector valve assembly 48 to be in fluid communication with passages (for example passage 30) to provide fluid to operate theactuators 28, as earlier described. - The differential pressure of the pressurized drilling causes the
first sealing surface 54 to load onto thesecond sealing surface 56. To reduce the amount of this hydraulic load,portions 56 of the total face area of the stationaryselector valve body 50 are relieved to reduce the surface area of the stationaryselector valve body 50 exposed to the differential pressure of the drilling fluid. The size of the outlet orifices 58 limits the total area of the stationaryselector valve body 50 that can be relieved. Therefore, the amount of surface area reduction is limited by the mechanical constraints of the valve. Typically, no more than about 50% of the total face area of the stationaryselector valve body 50 can be relieved. What remains is the sealing area. This does reduce the torque required to operate thevalve assembly 32. However, although relieving the sealingsurface 56 allows for more reliable operation, the differential pressure acting on the valve faces causes thevalve assembly 32 to stick at times in operation. - The effect of this differential pressure is particularly challenging upon initial startup of the
valve assembly 32. When thevalves bodies load spring 40 urges the valve's sealing surfaces 54, 56 together. This tends to squeeze out the fluid trapped between the valve sealing surfaces 54, 56 leading to hydraulic lock. - The
load spring 40 also urges the sealing surfaces 54, 56 back into contact during times in operation when they may separate. Although this is an unusual situation, it is possible that without theload spring 40, sealing surfaces 54, 56 would remain separated, rendering the tool inoperative. - Referring now to Figure 6, either or both of the
selector valve bodies selector valve body 48 with the sealingsurface 54 will be used to illustrate its operation, structure and composition. This is not intended to limit the invention to this particular valve body in any manner, as the porous structure may be in either or both of sealingsurfaces selector valve bodies - A common problem in prior selector valves was their tendency to exhibit very high starting torques at initial rotation after the pressurization of the drilling fluid. Oftentimes, this breakout torque was higher than what the roll stabilized
control unit 18 could provide and resulted in an expensive and time consuming 'trip' to replace or repair the valve. This torque is further exacerbated by the action of theload spring 40. - Reducing the surface area of the sealing surfaces 54, 56 helped to reduce the breakout torque. However, it has been found that when the sealing
surface 54 was provided with about 5% or more of its surface area comprisinginterconnected voids 60 with an average depth D of at least 0.02 mm, the breakout torque problem was practically eliminated. It is believed that theinterconnected voids 60 exposed at the surface allow limited fluid communication below the sealingsurface 54. This allows differential pressures to slowly equalize between the sealing surfaces 54, 65. This not only helps prevent hydraulic lock, it also provides a source of fluid for hydrodynamic lubrication of the sealingsurface 54. - One method to provide this porous structure is to make either or both
selector valve bodies surface 54 where a portion of the interstitial matrix adjacent to the sealingsurface 54 is substantially free of the catalyzing material, and the remaining interstitial matrix contains the catalyzing material. The portion of the interstitial matrix adjacent to the sealingsurface 54 that is free of the catalyzing material forms a porous surface with at least about 5% of its surface area comprisinginterconnected voids 60 with an average depth D of at least 0.02 mm from thesurface 54. In order for thevoids 60 to be interconnected below thesurface 54, they need to extend from thesurface 54 to a depth greater than the average diameter of the crystals. In the preferred embodiment, the depth D of theinterconnected voids 60 from thesurface 54 is a distance of at least 0.05 mm. The increased depth allows a more rapid equalization of pressures and provides more material at the sealingsurface 54 in the event it should wear in use. - Other suitable materials for the
selector valve bodies selector valve bodies surface 54 is treated to causevoids 60 to form below thesurface 54. Alternatively, the voids could be introduced into theselector valve bodies selector valve bodies surface 54 area is formed withinterconnected voids 60 extending to a depth D from the sealingsurface 54 of at least 0.02 mm. - There are many other materials and methods that may be suitable for providing a sealing
surface 54 with at least about 5% of its surface area comprisinginterconnected voids 60 with an average depth D from the sealingsurface 54 of at least 0.02 mm. - However, the effect of all is the same. The
interconnected voids 60 allow fluid pressure to equalize between the sealing faces by flowing through the interconnectingvoids 60 to the sealing surfaces 54, 56. Because the fit of the sealing surfaces 54, 56 valve is less than perfect, and because the voids on mating surfaces do not necessarily overlap, the 5% of the surface area comprisinginterconnected voids 60 can easily translate to a 10% or more reduction in sealed area when both sealingsurfaces - Whereas the present invention has been described in particular relation to the drawings attached hereto, it should be understood that other and further modifications apart from those shown or suggested herein, may be made within the scope and spirit of the present invention.
Claims (17)
- A rotary valve assembly for directing flow of a pressurized drilling fluid, the valve assembly comprising a first sealing surface rotatably engaging a second sealing surface, wherein an area of at least one of said sealing surfaces comprises at least about 5% interconnecting voids, the voids having an average depth from said one of said surfaces of at least 0.02 mm.
- The rotary valve assembly of claim 1 wherein the first sealing surface and the second sealing surface are preloaded with a load spring.
- The rotary valve assembly of claim 1 wherein the second sealing surface comprises a stationary selector valve body having a total face area, about 50% of said area relieved to decrease a hydraulic loading on the rotary valve assembly.
- The rotary valve assembly of claim 2 further comprising upper and lower seals, and upper and lower bearings contained in a spring housing.
- The rotary valve assembly of claim 4 arranged in flow communication with a plurality of spaced hydraulic actuators to supply the actuators the drilling fluid.
- The rotary valve assembly of claim 5 arranged within a roll stabilized bias unit, wherein the hydraulic actuators apply a lateral bias to a drill bit so as to provide directional control while drilling a borehole into the earth.
- The rotary valve assembly of claim 1 wherein the said one of said surfaces is formed of a polycrystalline diamond material having a plurality of partially bonded diamond crystals forming at least one continuous diamond matrix, and interstices among the diamond crystals forming at least one continuous interstitial matrix containing a catalyzing material, wherein a portion of the interstitial matrix adjacent to said one of said surfaces is substantially free of the catalyzing material, and the remaining interstitial matrix contains the catalyzing material.
- The rotary valve assembly of claim 7 wherein the portion of the interstitial matrix adjacent to said one of said surfaces that is free of the catalyzing material forms a porous surface of the interconnected voids.
- The rotary valve assembly of claim 8 wherein the diamond crystals have an average crystal size of greater than about 0.01 mm.
- The rotary valve assembly of claim 9 wherein the interconnected voids extend to a depth of at least 0.05 mm below said one of said surfaces.
- A rotary steerable tool comprising a rotary valve assembly for directing flow of a pressurized drilling fluid, the valve assembly comprising a first sealing surface rotatably engaging a second sealing surface, wherein an area of at least one of said surfaces comprises at least about 5% interconnecting voids, the voids having an average depth from said one of said surfaces of at least 0.02 mm, the valve assembly arranged in flow communication with a plurality of spaced hydraulic actuators to supply the actuators the drilling fluid and arranged within a roll stabilized bias unit, wherein the hydraulic actuators apply a lateral bias to a drill bit so as to provide directional control while drilling a borehole into the earth.
- The rotary steerable tool of claim 11 wherein said one of said surfaces is formed of a polycrystalline diamond material having a plurality of partially bonded diamond crystals forming at least one continuous diamond matrix, and interstices among the diamond crystals forming at least one continuous interstitial matrix containing a catalyzing material, wherein a portion of the interstitial matrix adjacent to said one of said surfaces is substantially free of the catalyzing material, and the remaining interstitial matrix contains the catalyzing material.
- The rotary steerable tool of claim 12 wherein the portion of the interstitial matrix adjacent to said one of said surfaces that is free of the catalyzing material forms a porous surface of the interconnected voids.
- The rotary steerable tool of claim 13 wherein the diamond crystals have an average crystal size of greater than about 0.01 mm.
- The rotary valve assembly of claim 14 wherein the interconnected voids extend to a depth of at least 0.05 mm below said one of said surfaces.
- The rotary steerable tool of claim 11 wherein the second sealing surface comprises a stationary selector valve body having an area, about 50% of said area relieved to decrease a hydraulic loading on the rotary valve assembly.
- The rotary steerable tool of claim 16 wherein the first sealing surface and the second sealing surface are preloaded with a load spring.
Applications Claiming Priority (4)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US683358 | 1991-04-10 | ||
US28105401P | 2001-04-02 | 2001-04-02 | |
US281054P | 2001-04-02 | ||
US09/683,358 US6962214B2 (en) | 2001-04-02 | 2001-12-18 | Rotary seal for directional drilling tools |
Publications (2)
Publication Number | Publication Date |
---|---|
EP1247787A1 true EP1247787A1 (en) | 2002-10-09 |
EP1247787B1 EP1247787B1 (en) | 2012-10-17 |
Family
ID=26960676
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
EP02251373A Expired - Fee Related EP1247787B1 (en) | 2001-04-02 | 2002-02-27 | Rotary seal for directional drilling tools |
Country Status (4)
Country | Link |
---|---|
US (1) | US6962214B2 (en) |
EP (1) | EP1247787B1 (en) |
CA (1) | CA2379806C (en) |
NO (1) | NO325471B1 (en) |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2019017872A1 (en) | 2017-07-17 | 2019-01-24 | Halliburton Energy Services, Inc. | A rotary valve with valve seat engagement compensation |
US11236583B2 (en) | 2017-12-29 | 2022-02-01 | Halliburton Energy Services, Inc. | Steering system for use with a drill string |
Families Citing this family (27)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US7681669B2 (en) | 2005-01-17 | 2010-03-23 | Us Synthetic Corporation | Polycrystalline diamond insert, drill bit including same, and method of operation |
GB2425790B (en) * | 2005-05-05 | 2010-09-01 | Schlumberger Holdings | Steerable drilling system |
US8590636B2 (en) * | 2006-04-28 | 2013-11-26 | Schlumberger Technology Corporation | Rotary steerable drilling system |
GB2450498A (en) * | 2007-06-26 | 2008-12-31 | Schlumberger Holdings | Battery powered rotary steerable drilling system |
US8172007B2 (en) * | 2007-12-13 | 2012-05-08 | Intelliserv, LLC. | System and method of monitoring flow in a wellbore |
US20090151939A1 (en) * | 2007-12-13 | 2009-06-18 | Schlumberger Technology Corporation | Surface tagging system with wired tubulars |
CA2748711C (en) | 2009-01-30 | 2014-07-08 | Drilformance Ulc | Drill bit |
US7972395B1 (en) | 2009-04-06 | 2011-07-05 | Us Synthetic Corporation | Superabrasive articles and methods for removing interstitial materials from superabrasive materials |
US8951317B1 (en) | 2009-04-27 | 2015-02-10 | Us Synthetic Corporation | Superabrasive elements including ceramic coatings and methods of leaching catalysts from superabrasive elements |
US9352447B2 (en) | 2009-09-08 | 2016-05-31 | Us Synthetic Corporation | Superabrasive elements and methods for processing and manufacturing the same using protective layers |
ES2623911T3 (en) | 2010-09-09 | 2017-07-12 | National Oilwell Varco, L.P. | Rotary drilling device for well bottom with members of training interface and control system |
US8869916B2 (en) | 2010-09-09 | 2014-10-28 | National Oilwell Varco, L.P. | Rotary steerable push-the-bit drilling apparatus with self-cleaning fluid filter |
US8376067B2 (en) * | 2010-12-23 | 2013-02-19 | Schlumberger Technology Corporation | System and method employing a rotational valve to control steering in a rotary steerable system |
US9144886B1 (en) | 2011-08-15 | 2015-09-29 | Us Synthetic Corporation | Protective leaching cups, leaching trays, and methods for processing superabrasive elements using protective leaching cups and leaching trays |
US8961630B2 (en) | 2012-05-04 | 2015-02-24 | Baker Hughes Incorporated | Methods of forming cutting elements by removing metal from interstitial spaces in polycrystalline diamond |
US9970235B2 (en) | 2012-10-15 | 2018-05-15 | Bertrand Lacour | Rotary steerable drilling system for drilling a borehole in an earth formation |
US9550276B1 (en) | 2013-06-18 | 2017-01-24 | Us Synthetic Corporation | Leaching assemblies, systems, and methods for processing superabrasive elements |
US9789587B1 (en) | 2013-12-16 | 2017-10-17 | Us Synthetic Corporation | Leaching assemblies, systems, and methods for processing superabrasive elements |
US10807913B1 (en) | 2014-02-11 | 2020-10-20 | Us Synthetic Corporation | Leached superabrasive elements and leaching systems methods and assemblies for processing superabrasive elements |
US9908215B1 (en) | 2014-08-12 | 2018-03-06 | Us Synthetic Corporation | Systems, methods and assemblies for processing superabrasive materials |
US11766761B1 (en) | 2014-10-10 | 2023-09-26 | Us Synthetic Corporation | Group II metal salts in electrolytic leaching of superabrasive materials |
US10011000B1 (en) | 2014-10-10 | 2018-07-03 | Us Synthetic Corporation | Leached superabrasive elements and systems, methods and assemblies for processing superabrasive materials |
US10723626B1 (en) | 2015-05-31 | 2020-07-28 | Us Synthetic Corporation | Leached superabrasive elements and systems, methods and assemblies for processing superabrasive materials |
WO2017172563A1 (en) | 2016-03-31 | 2017-10-05 | Schlumberger Technology Corporation | Equipment string communication and steering |
BR112019005283A2 (en) * | 2016-10-19 | 2019-06-04 | Halliburton Energy Services Inc | rotary valve, and method of manufacturing a rotary valve |
US10900291B2 (en) | 2017-09-18 | 2021-01-26 | Us Synthetic Corporation | Polycrystalline diamond elements and systems and methods for fabricating the same |
US10544650B2 (en) | 2017-10-29 | 2020-01-28 | Weatherford Technology Holdings, Llc | Rotating disk valve for rotary steerable tool |
Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4224380A (en) | 1978-03-28 | 1980-09-23 | General Electric Company | Temperature resistant abrasive compact and method for making same |
EP0617207A2 (en) | 1993-03-26 | 1994-09-28 | De Beers Industrial Diamond Division (Proprietary) Limited | Bearing assembly |
Family Cites Families (49)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3123162A (en) | 1964-03-03 | Xsill string stabilizer | ||
US712887A (en) | 1900-05-09 | 1902-11-04 | Josef Wyczynski | Centering and guiding device for deep-boring apparatus with eccentric boring-tool. |
US1971480A (en) | 1931-06-25 | 1934-08-28 | J S Abercrombie Company | Means and method of straightening well bores |
US2345766A (en) | 1940-12-02 | 1944-04-04 | Eastman Oil Well Survey Co | Deflecting tool |
US2585207A (en) | 1950-10-11 | 1952-02-12 | John A Zublin | Apparatus for drilling lateral bores deviating from vertical well bores |
US2694549A (en) | 1952-01-21 | 1954-11-16 | Eastman Oil Well Survey Co | Joint structure between flexible shafting and drill bit structure for drilling lateral bores |
US2687282A (en) | 1952-01-21 | 1954-08-24 | Eastman Oil Well Survey Co | Reaming bit structure for earth bores |
US2712434A (en) | 1953-11-23 | 1955-07-05 | Melvin L Giles | Directional drilling tool |
US2857141A (en) | 1957-04-25 | 1958-10-21 | Frank H Carpenter | Well tool |
US3062303A (en) | 1960-03-21 | 1962-11-06 | Shell Oil Co | Method and apparatus for controlling hole direction and inclination |
US3092188A (en) | 1961-07-31 | 1963-06-04 | Whipstock Inc | Directional drilling tool |
US3225843A (en) | 1961-09-14 | 1965-12-28 | Exxon Production Research Co | Bit loading apparatus |
US3512592A (en) | 1968-03-14 | 1970-05-19 | Exxon Production Research Co | Offshore drilling method and apparatus |
US3997008A (en) | 1974-09-13 | 1976-12-14 | Smith International, Inc. | Drill director |
US4022287A (en) | 1976-04-20 | 1977-05-10 | Sandvik Aktiebolag | Percussion drill bit |
CA1095023A (en) | 1977-07-20 | 1981-02-03 | John Roddy | Rock drill bit loading device |
US4211292A (en) | 1978-07-27 | 1980-07-08 | Evans Robert F | Borehole angle control by gage corner removal effects |
US4305474A (en) | 1980-02-04 | 1981-12-15 | Conoco Inc. | Thrust actuated drill guidance device |
US4416339A (en) | 1982-01-21 | 1983-11-22 | Baker Royce E | Bit guidance device and method |
US4449595A (en) | 1982-05-17 | 1984-05-22 | Holbert Don R | Method and apparatus for drilling a curved bore |
US4635736A (en) | 1985-11-22 | 1987-01-13 | Shirley Kirk R | Drill steering apparatus |
US4690229A (en) | 1986-01-22 | 1987-09-01 | Raney Richard C | Radially stabilized drill bit |
US4842083A (en) | 1986-01-22 | 1989-06-27 | Raney Richard C | Drill bit stabilizer |
US4699224A (en) | 1986-05-12 | 1987-10-13 | Sidewinder Joint Venture | Method and apparatus for lateral drilling in oil and gas wells |
GB2190411B (en) | 1986-05-16 | 1990-02-21 | Shell Int Research | Apparatus for directional drilling. |
WO1988010355A1 (en) | 1987-06-16 | 1988-12-29 | Preussag Aktiengesellschaft | Device for guiding a drilling tool and/or pipe string |
EP0324870B1 (en) | 1988-01-19 | 1991-07-10 | SCHWING HYDRAULIK ELEKTRONIK GMBH & CO. | Self-steering drill string pipe for rotating drill strings of rock drilling machines |
US4886130A (en) | 1988-07-26 | 1989-12-12 | Evans Robert F | Nutational technique for limiting well bore deviation |
CA2002135C (en) | 1988-11-03 | 1999-02-02 | James Bain Noble | Directional drilling apparatus and method |
US5109935A (en) | 1989-11-25 | 1992-05-05 | Reed Tool Company Limited | Rotary drill bits |
GB8926689D0 (en) | 1989-11-25 | 1990-01-17 | Reed Tool Co | Improvements in or relating to rotary drill bits |
US4948925A (en) | 1989-11-30 | 1990-08-14 | Amoco Corporation | Apparatus and method for rotationally orienting a fluid conducting conduit |
DE4017761A1 (en) | 1990-06-01 | 1991-12-05 | Eastman Christensen Co | DRILLING TOOL FOR DRILLING HOLES IN SUBSTRATE ROCK INFORMATION |
US5103919A (en) | 1990-10-04 | 1992-04-14 | Amoco Corporation | Method of determining the rotational orientation of a downhole tool |
US5265682A (en) | 1991-06-25 | 1993-11-30 | Camco Drilling Group Limited | Steerable rotary drilling systems |
US5553678A (en) | 1991-08-30 | 1996-09-10 | Camco International Inc. | Modulated bias units for steerable rotary drilling systems |
FR2713700B1 (en) | 1993-12-08 | 1996-03-15 | Inst Francais Du Petrole | Method and system for controlling the stability of the rotation speed of a drilling tool. |
GB9411228D0 (en) | 1994-06-04 | 1994-07-27 | Camco Drilling Group Ltd | A modulated bias unit for rotary drilling |
GB9503830D0 (en) | 1995-02-25 | 1995-04-19 | Camco Drilling Group Ltd | "Improvements in or relating to steerable rotary drilling systems" |
GB9503827D0 (en) | 1995-02-25 | 1995-04-19 | Camco Drilling Group Ltd | "Improvements in or relating to steerable rotary drilling systems |
GB9503829D0 (en) | 1995-02-25 | 1995-04-19 | Camco Drilling Group Ltd | "Improvememnts in or relating to steerable rotary drilling systems" |
GB9503828D0 (en) | 1995-02-25 | 1995-04-19 | Camco Drilling Group Ltd | "Improvements in or relating to steerable rotary drilling systems" |
GB2322651B (en) | 1996-11-06 | 2000-09-20 | Camco Drilling Group Ltd | A downhole unit for use in boreholes in a subsurface formation |
GB9708428D0 (en) | 1997-04-26 | 1997-06-18 | Camco Int Uk Ltd | Improvements in or relating to rotary drill bits |
US6092610A (en) | 1998-02-05 | 2000-07-25 | Schlumberger Technology Corporation | Actively controlled rotary steerable system and method for drilling wells |
CA2334334C (en) | 1998-06-08 | 2007-10-09 | Charles T. Webb | Directional drilling system and apparatus |
US6109372A (en) | 1999-03-15 | 2000-08-29 | Schlumberger Technology Corporation | Rotary steerable well drilling system utilizing hydraulic servo-loop |
US6116354A (en) | 1999-03-19 | 2000-09-12 | Weatherford/Lamb, Inc. | Rotary steerable system for use in drilling deviated wells |
WO2001034935A1 (en) | 1999-11-10 | 2001-05-17 | Schlumberger Holdings Limited | Control method for use with a steerable drilling system |
-
2001
- 2001-12-18 US US09/683,358 patent/US6962214B2/en not_active Expired - Fee Related
-
2002
- 2002-02-27 EP EP02251373A patent/EP1247787B1/en not_active Expired - Fee Related
- 2002-03-15 NO NO20021290A patent/NO325471B1/en not_active IP Right Cessation
- 2002-03-28 CA CA002379806A patent/CA2379806C/en not_active Expired - Fee Related
Patent Citations (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4224380A (en) | 1978-03-28 | 1980-09-23 | General Electric Company | Temperature resistant abrasive compact and method for making same |
EP0617207A2 (en) | 1993-03-26 | 1994-09-28 | De Beers Industrial Diamond Division (Proprietary) Limited | Bearing assembly |
Cited By (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2019017872A1 (en) | 2017-07-17 | 2019-01-24 | Halliburton Energy Services, Inc. | A rotary valve with valve seat engagement compensation |
EP3615765A4 (en) * | 2017-07-17 | 2020-12-16 | Halliburton Energy Services, Inc. | A rotary valve with valve seat engagement compensation |
EP3896248A1 (en) * | 2017-07-17 | 2021-10-20 | Halliburton Energy Services, Inc. | A rotary valve with valve seat engagement compensation |
US11566481B2 (en) | 2017-07-17 | 2023-01-31 | Halliburton Energy Services, Inc. | Rotary valve with valve seat engagement compensation |
US11236583B2 (en) | 2017-12-29 | 2022-02-01 | Halliburton Energy Services, Inc. | Steering system for use with a drill string |
US11773685B2 (en) | 2017-12-29 | 2023-10-03 | Halliburton Energy Services, Inc. | Steering system for use with a drill string |
Also Published As
Publication number | Publication date |
---|---|
CA2379806A1 (en) | 2002-10-02 |
NO20021290D0 (en) | 2002-03-15 |
US6962214B2 (en) | 2005-11-08 |
US20020139584A1 (en) | 2002-10-03 |
CA2379806C (en) | 2009-11-03 |
NO20021290L (en) | 2002-10-03 |
EP1247787B1 (en) | 2012-10-17 |
NO325471B1 (en) | 2008-05-05 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US6962214B2 (en) | Rotary seal for directional drilling tools | |
US8627893B2 (en) | Apparatus and method for selective flow control | |
US6033117A (en) | Sealed bearing drill bit with dual-seal configuration | |
EP0685623B1 (en) | A rotatable pressure seal | |
US9752386B2 (en) | Steerable drilling system | |
US4811798A (en) | Drilling motor deviation tool | |
US6254275B1 (en) | Sealed bearing drill bit with dual-seal configuration and fluid-cleaning capability | |
US4620601A (en) | Well drilling tool with diamond thrust bearings | |
US7036611B2 (en) | Expandable reamer apparatus for enlarging boreholes while drilling and methods of use | |
US8245796B2 (en) | Tractor with improved valve system | |
AU641569B2 (en) | Disc drill bit | |
US20020112859A1 (en) | Tractor with improved valve system | |
NO339967B1 (en) | System, apparatus and method for activating a tool for use in a wellbore | |
CA2978154C (en) | Apparatus and method for directional drilling of boreholes | |
EP2880243B1 (en) | Rotary steerable drilling system | |
US20180363380A1 (en) | Downhole adjustable bend assemblies | |
DE112008003250T5 (en) | Arrangement and method for a hydraulic borehole mud motor with diaphragm | |
US6802380B2 (en) | Pressure relief system and methods of use and making | |
US20230167689A1 (en) | Fixed cutter drill bit with high fluid pressures | |
EP1275815B1 (en) | Drill Bit Having Adjustable Total Flow Area | |
NO325654B1 (en) | Two-stage filter for drilling fluid and associated downhole tools | |
EP1828535B1 (en) | Micropore engagement surfaces for earth boring bit | |
AU784447B2 (en) | Rotary seal for directional drilling tools | |
CN104508230A (en) | Drill bit with hydraulically adjustable axial pad for controlling torsional fluctuations | |
US11753907B2 (en) | Pressure adjuster for a downhole tool |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
PUAI | Public reference made under article 153(3) epc to a published international application that has entered the european phase |
Free format text: ORIGINAL CODE: 0009012 |
|
AK | Designated contracting states |
Kind code of ref document: A1 Designated state(s): AT BE CH CY DE DK ES FI FR GB GR IE IT LI LU MC NL PT SE TR |
|
AX | Request for extension of the european patent |
Free format text: AL;LT;LV;MK;RO;SI |
|
17P | Request for examination filed |
Effective date: 20030310 |
|
AKX | Designation fees paid |
Designated state(s): BE DE FR GB IE IT |
|
17Q | First examination report despatched |
Effective date: 20091008 |
|
REG | Reference to a national code |
Ref country code: DE Ref legal event code: R079 Ref document number: 60243868 Country of ref document: DE Free format text: PREVIOUS MAIN CLASS: C04B0035520000 Ipc: B22F0007060000 |
|
GRAP | Despatch of communication of intention to grant a patent |
Free format text: ORIGINAL CODE: EPIDOSNIGR1 |
|
RIC1 | Information provided on ipc code assigned before grant |
Ipc: C04B 41/45 20060101ALI20120326BHEP Ipc: C04B 41/91 20060101ALI20120326BHEP Ipc: C04B 41/81 20060101ALI20120326BHEP Ipc: C04B 41/53 20060101ALI20120326BHEP Ipc: E21B 21/10 20060101ALI20120326BHEP Ipc: B22F 7/06 20060101AFI20120326BHEP Ipc: B23B 27/14 20060101ALI20120326BHEP Ipc: C04B 35/52 20060101ALI20120326BHEP Ipc: F16K 25/00 20060101ALI20120326BHEP Ipc: F16C 33/04 20060101ALI20120326BHEP Ipc: C04B 37/02 20060101ALI20120326BHEP |
|
GRAS | Grant fee paid |
Free format text: ORIGINAL CODE: EPIDOSNIGR3 |
|
GRAA | (expected) grant |
Free format text: ORIGINAL CODE: 0009210 |
|
AK | Designated contracting states |
Kind code of ref document: B1 Designated state(s): BE DE FR GB IE IT |
|
REG | Reference to a national code |
Ref country code: GB Ref legal event code: FG4D |
|
REG | Reference to a national code |
Ref country code: IE Ref legal event code: FG4D |
|
REG | Reference to a national code |
Ref country code: DE Ref legal event code: R096 Ref document number: 60243868 Country of ref document: DE Effective date: 20121213 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: BE Free format text: LAPSE BECAUSE OF FAILURE TO SUBMIT A TRANSLATION OF THE DESCRIPTION OR TO PAY THE FEE WITHIN THE PRESCRIBED TIME-LIMIT Effective date: 20121017 |
|
PLBE | No opposition filed within time limit |
Free format text: ORIGINAL CODE: 0009261 |
|
STAA | Information on the status of an ep patent application or granted ep patent |
Free format text: STATUS: NO OPPOSITION FILED WITHIN TIME LIMIT |
|
26N | No opposition filed |
Effective date: 20130718 |
|
REG | Reference to a national code |
Ref country code: DE Ref legal event code: R097 Ref document number: 60243868 Country of ref document: DE Effective date: 20130718 |
|
REG | Reference to a national code |
Ref country code: FR Ref legal event code: ST Effective date: 20131031 |
|
REG | Reference to a national code |
Ref country code: IE Ref legal event code: MM4A |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: FR Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20130228 Ref country code: IE Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20130227 |
|
PGFP | Annual fee paid to national office [announced via postgrant information from national office to epo] |
Ref country code: DE Payment date: 20140417 Year of fee payment: 13 |
|
PGFP | Annual fee paid to national office [announced via postgrant information from national office to epo] |
Ref country code: IT Payment date: 20150216 Year of fee payment: 14 |
|
REG | Reference to a national code |
Ref country code: DE Ref legal event code: R119 Ref document number: 60243868 Country of ref document: DE |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: DE Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20150901 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: IT Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20160227 |
|
PGFP | Annual fee paid to national office [announced via postgrant information from national office to epo] |
Ref country code: GB Payment date: 20170228 Year of fee payment: 16 |
|
GBPC | Gb: european patent ceased through non-payment of renewal fee |
Effective date: 20180227 |
|
PG25 | Lapsed in a contracting state [announced via postgrant information from national office to epo] |
Ref country code: GB Free format text: LAPSE BECAUSE OF NON-PAYMENT OF DUE FEES Effective date: 20180227 |